Floating Liquefied Natural Gas Market by Containment System (Membrane, Moss), Vessel Type (FLNG, FSRU, FSU), Technology, Storage Capacity, Operational Status, Application, End User - Global Forecast 2025-2032
Description
The Floating Liquefied Natural Gas Market was valued at USD 17.94 billion in 2024 and is projected to grow to USD 18.96 billion in 2025, with a CAGR of 5.62%, reaching USD 27.80 billion by 2032.
A compact but authoritative introduction that positions floating liquefied natural gas as a strategic, technical, and commercial proposition for modern energy portfolios
Floating liquefied natural gas (FLNG) has evolved from a niche engineering concept into a strategic option for nations and corporations seeking flexible, lower-footprint LNG solutions. Moving production, liquefaction, and storage offshore has introduced a new set of commercial and technical trade-offs that influence how projects are conceived, financed, and executed. Recent advances in hull design, containment systems, and liquefaction cycles have reduced unit complexity while increasing operational agility, enabling projects that previously were not viable because of onshore constraints or permitting hurdles.
The technology has matured in parallel with shifting global demand patterns and evolving regulatory expectations around emissions and marine safety. Consequently, developers now weigh lifecycle emissions, methane management, and integration with onshore logistics more heavily during pre-FEED and FEED phases. At the same time, financiers and offtakers are scrutinizing execution risk and contractor track records, prompting a layered approach to contracting that blends EPC scopes with long-term service agreements and digital operations contracts. This introduction frames the subsequent analysis of structural shifts, tariff impacts, segmentation nuances, regional dynamics, and recommended actions for industry leaders navigating a rapidly changing FLNG environment.
An incisive exploration of the major technological, regulatory, and capital-market shifts that are redefining floating liquefied natural gas project economics and deployment choices
The landscape for floating liquefied natural gas is being reshaped by several concurrent transformative shifts that intersect technology, policy, and capital allocation. On the technological front, the convergence of modular engineering, advanced refrigerant cycles, and containment innovations has compressed project schedules and reduced vessel-level risk. Operators are adopting digital twins, predictive maintenance, and remote operations frameworks that lower downtime and extend maintenance intervals, which in turn improves operational predictability for long-term contracts and spot trading strategies.
Policy and regulatory evolution is also a defining force. Stricter greenhouse gas reporting, methane monitoring mandates, and tighter shipboard emission standards are driving equipment upgrades and adding new compliance disciplines into front-end planning. Investors increasingly subject projects to environmental and governance screens, directing capital toward proposals with measurable emissions reduction plans and robust leak-detection protocols. Finally, shifting demand patterns-driven by electrification, seasonal consumption swings, and the geopolitical reorientation of gas flows-are influencing the preferred configurations of floating assets, nudging the market toward more flexible, shorter-lead-time solutions that can be redeployed across regions as commercial conditions change.
A comprehensive assessment of how new United States tariff measures for 2025 could cumulatively alter procurement practices, supply chains, and project timelines across the floating LNG value chain
Anticipated tariff actions announced by the United States for 2025 introduce a complex set of trade and supply-chain effects that cumulative analysis must treat carefully. Tariff increases on imported components and fabricated modules tend to elevate the cost basis for externally sourced equipment, prompting project teams to revisit procurement strategies and, in some cases, accelerate localization or nearshoring of critical subsystems. This dynamic creates secondary impacts across supplier selection, contract terms, and delivery timelines, particularly where key cryogenic or containment components originate from a concentrated supplier base.
In response, developers and EPC contractors are evaluating contract rebalancing to mitigate exposure, including revisiting risk-sharing clauses and extending onshore preassembly work that can absorb tariff impacts. At the same time, tariffs can incentivize domestic fabrication capacity expansion and joint ventures between international technology owners and local yards, thereby altering the industrial footprint of the value chain. Financial stakeholders may request updated cost and schedule risk analyses to reflect these policy shifts, and insurers may recalibrate policy terms where procurement strategies materially increase lead times or supply concentration risk. Collectively, these effects operate as a set of structural adjustments rather than a single-point shock, with the potential to lengthen project readiness timelines while simultaneously accelerating strategic moves toward diversified sourcing and localized manufacturing partnerships.
A detailed and integrated segmentation analysis that connects containment choices, vessel classes, liquefaction technology, and application demands to practical deployment decisions and contracting outcomes
Segmentation insights clarify where technical choices and commercial use cases intersect to shape deployment pathways and tender specifications. Based on Containment System, market is studied across Membrane and Moss, and this distinction governs not only initial capex and maintainability but also implications for payload efficiency, inspection regimes, and cold chain interfaces. Based on Vessel Type, market is studied across FLNG, FSRU, and FSU, with each vessel class offering distinct operational profiles: FLNGs integrate upstream processing and liquefaction, FSRUs focus on regasification and shore supply flexibility, and FSUs provide strategic storage and bridging capacity for market imbalances. Based on Technology, market is studied across C3MR, Mixed Refrigerant, and Propane Precooling; the Mixed Refrigerant is further studied across Dual Mixed Refrigerant and Single Mixed Refrigerant, and these selection pathways influence plant footprint, start-up behavior, turndown performance, and refrigerant handling protocols.
Based on Application, market is studied across Industrial Process, Power Generation, Regasification, and Shipping Fuel, which determines duty cycles, contract tenor expectations, and integration with onshore receiving terminals. Based on Storage Capacity, market is studied across 100 To 180 K Cubic Meter, Above 180 K Cubic Meter, and Up To 100 K Cubic Meter, and capacity thresholds affect mooring arrangements, transshipment approaches, and commercial flexibility for spot cargo handling. Based on End User, market is studied across Industrial Manufacturing, Petrochemicals, Transportation, and Utilities, and each end user group has differing risk appetites, payment structures, and technical integration needs. Based on Operational Status, market is studied across Operational, Planned, and Under Construction, which provides a lens on execution performance, asset readiness, and near-term supply availability. Together, these segmentation lenses enable stakeholders to map technology choices to specific business objectives and regulatory contexts.
A regionally focused synthesis that explains how Americas, Europe Middle East & Africa, and Asia-Pacific dynamics shape project design, contracting, and deployment sequencing for floating LNG
Regional dynamics continue to exert outsized influence on where floating liquefied natural gas projects are prioritized and how they are structured commercially. In the Americas, the proximity to large gas basins and established maritime infrastructure supports a mix of export-oriented and domestic use cases; project sponsors often benefit from deep fabrication capacity and a competitive supply base, while regional regulatory frameworks emphasize safety and environmental oversight. In Europe, Middle East & Africa, the landscape is heterogeneous: the Middle East hosts competitive feedstock and capital availability that favors large-scale, longer-duration projects, Europe is focused on energy security and decarbonization which elevates flexibility and emissions credentials, and parts of Africa present high upside for gas monetization using floating solutions where onshore infrastructure is limited.
Asia-Pacific continues to be the primary demand hub, driven by population centers with growing gas consumption and a strong appetite for diverse supply sources. The region’s demand profile has encouraged the adoption of FSRUs to rapidly increase import capacity and FLNG solutions in select offshore fields where onshore development is constrained. Across all regions, policy drivers such as carbon pricing, methane regulation, and local content rules are shaping contracting strategies and investor due diligence. These regional contours determine vessel routing, mooring solutions, and commercial structures, and they should inform where capital is allocated and which technical designs are prioritized for competitive tendering.
An authoritative overview of the competitive ecosystem and service-provider landscape that highlights execution capabilities, partnership models, and aftermarket value propositions essential to floating LNG success
The competitive field for floating liquefied natural gas is characterized by a small number of specialized technology licensors, major shipyards with integrated fabrication capabilities, and a growing set of service providers that focus on digital operations, cryogenic maintenance, and lifecycle support. These players compete on execution track record, technology robustness, vessel reliability, and the ability to provide integrated service packages that span EPC, long-term operations, and spare parts supply. Partnerships and consortiums remain a common strategy to distribute execution risk and to combine upstream expertise with marine engineering and port services.
In addition to pure-play technology suppliers and shipbuilders, increasingly important roles are being played by engineering contractors who can offer modularized delivery models that reduce interface complexity and shorten commissioning windows. The aftermarket and operations segment is also evolving: specialized providers offering remote monitoring, emissions detection, and predictive maintenance services are adding tangible value by lowering operational interruptions and enabling more precise performance guarantees. Finally, financiers and insurers with sector specialization are influencing contractual norms by requiring enhanced due diligence on supply chains, environmental risk, and operational resilience, which in turn shapes how companies position their capabilities to win contracts in a more discerning procurement environment.
Practical and prioritized strategic recommendations for industry leaders to strengthen supply chains, embed emissions controls, and structure flexible commercial contracts to de-risk floating LNG initiatives
Industry leaders should adopt a pragmatic set of actions to capture opportunity while managing execution and policy risks. First, prioritize supply-chain diversification and nearshoring strategies that reduce exposure to tariff shocks and single-source dependencies. This includes qualifying alternate fabricators and negotiating staged delivery terms that align payment milestones with demonstrable progress. Second, integrate emissions management and methane-detection technologies into early design stages to meet tightening regulatory expectations and to preserve offtaker and investor confidence. Embedding leak detection and low-emissions compressors at FEED can materially lower retrofit risk later in an asset’s life.
Third, structure commercial contracts with flexible redeployment clauses and hybrid pricing mechanisms that allow assets to move between export, regasification, and storage duties without onerous penalties. Fourth, invest in digital operations and predictive maintenance capabilities to extend mean time between failures and to reduce planned downtime windows, thus protecting revenue streams. Fifth, pursue strategic alliances with local partners to navigate regulatory landscapes and to access regional incentives. Finally, engage proactively with insurers and lenders early in the design process to align risk transfer mechanisms and to avoid last-minute underwriting constraints that can delay financial close.
A transparent description of the mixed-methods research approach that combines primary interviews, technical literature, and corroborating operational evidence to derive actionable insights for stakeholders
This study draws on a blended research methodology that combines technical literature review, primary stakeholder engagement, and cross-validation with operational data from active floating assets. Primary engagement included structured interviews with project developers, shipbuilders, technology licensors, operators, and financiers to surface execution challenges, procurement adaptations, and evolving contractual norms. Technical literature and industry standards provided the foundation for assessing containment systems, refrigerant cycles, and vessel classes, while regulatory documentation informed the analysis of emissions and compliance trends.
Where possible, findings were corroborated through operator disclosures, public filings, and third-party engineering assessments to ensure alignment between stated practices and observed operational outcomes. Scenario analysis was applied qualitatively to explore how tariff measures, policy changes, and supply-chain shifts might influence procurement and scheduling decisions, and sensitivity considerations were used to surface potential inflection points for strategy. The methodology emphasizes triangulation across sources and disciplines to produce insights that are both actionable for practitioners and robust under a range of commercial and policy conditions.
A concise conclusion that synthesizes the strategic imperatives and execution criteria essential for successful floating LNG project development and long-term operational resilience
In conclusion, floating liquefied natural gas represents a versatile set of technical and commercial solutions that can address specific resource, regulatory, and market constraints when deployed with disciplined procurement, emissions-conscious design, and adaptive commercial structures. The convergence of modular engineering, advanced refrigeration cycles, and digital operations increases the viability of floating solutions across a wider set of geographies and use cases than previously feasible. However, the environment is complex: policy changes such as tariffs and emissions mandates introduce layers of strategic uncertainty that must be managed through diversified sourcing, early stakeholder alignment, and contract structures that permit flexibility.
Looking ahead, the projects that will succeed are those that combine technical robustness with agile commercial design, transparent emissions governance, and proven execution partners. By foregrounding supply-chain resilience, local partnerships, and digital-enabled maintenance, developers and operators can better control schedule risk and sustain operational performance. The concluding message is that thoughtful integration of technical choices with commercial strategy and regulatory foresight will be the differentiator between projects that meet stakeholder expectations and those that face costly delays or reputational risk.
Note: PDF & Excel + Online Access - 1 Year
A compact but authoritative introduction that positions floating liquefied natural gas as a strategic, technical, and commercial proposition for modern energy portfolios
Floating liquefied natural gas (FLNG) has evolved from a niche engineering concept into a strategic option for nations and corporations seeking flexible, lower-footprint LNG solutions. Moving production, liquefaction, and storage offshore has introduced a new set of commercial and technical trade-offs that influence how projects are conceived, financed, and executed. Recent advances in hull design, containment systems, and liquefaction cycles have reduced unit complexity while increasing operational agility, enabling projects that previously were not viable because of onshore constraints or permitting hurdles.
The technology has matured in parallel with shifting global demand patterns and evolving regulatory expectations around emissions and marine safety. Consequently, developers now weigh lifecycle emissions, methane management, and integration with onshore logistics more heavily during pre-FEED and FEED phases. At the same time, financiers and offtakers are scrutinizing execution risk and contractor track records, prompting a layered approach to contracting that blends EPC scopes with long-term service agreements and digital operations contracts. This introduction frames the subsequent analysis of structural shifts, tariff impacts, segmentation nuances, regional dynamics, and recommended actions for industry leaders navigating a rapidly changing FLNG environment.
An incisive exploration of the major technological, regulatory, and capital-market shifts that are redefining floating liquefied natural gas project economics and deployment choices
The landscape for floating liquefied natural gas is being reshaped by several concurrent transformative shifts that intersect technology, policy, and capital allocation. On the technological front, the convergence of modular engineering, advanced refrigerant cycles, and containment innovations has compressed project schedules and reduced vessel-level risk. Operators are adopting digital twins, predictive maintenance, and remote operations frameworks that lower downtime and extend maintenance intervals, which in turn improves operational predictability for long-term contracts and spot trading strategies.
Policy and regulatory evolution is also a defining force. Stricter greenhouse gas reporting, methane monitoring mandates, and tighter shipboard emission standards are driving equipment upgrades and adding new compliance disciplines into front-end planning. Investors increasingly subject projects to environmental and governance screens, directing capital toward proposals with measurable emissions reduction plans and robust leak-detection protocols. Finally, shifting demand patterns-driven by electrification, seasonal consumption swings, and the geopolitical reorientation of gas flows-are influencing the preferred configurations of floating assets, nudging the market toward more flexible, shorter-lead-time solutions that can be redeployed across regions as commercial conditions change.
A comprehensive assessment of how new United States tariff measures for 2025 could cumulatively alter procurement practices, supply chains, and project timelines across the floating LNG value chain
Anticipated tariff actions announced by the United States for 2025 introduce a complex set of trade and supply-chain effects that cumulative analysis must treat carefully. Tariff increases on imported components and fabricated modules tend to elevate the cost basis for externally sourced equipment, prompting project teams to revisit procurement strategies and, in some cases, accelerate localization or nearshoring of critical subsystems. This dynamic creates secondary impacts across supplier selection, contract terms, and delivery timelines, particularly where key cryogenic or containment components originate from a concentrated supplier base.
In response, developers and EPC contractors are evaluating contract rebalancing to mitigate exposure, including revisiting risk-sharing clauses and extending onshore preassembly work that can absorb tariff impacts. At the same time, tariffs can incentivize domestic fabrication capacity expansion and joint ventures between international technology owners and local yards, thereby altering the industrial footprint of the value chain. Financial stakeholders may request updated cost and schedule risk analyses to reflect these policy shifts, and insurers may recalibrate policy terms where procurement strategies materially increase lead times or supply concentration risk. Collectively, these effects operate as a set of structural adjustments rather than a single-point shock, with the potential to lengthen project readiness timelines while simultaneously accelerating strategic moves toward diversified sourcing and localized manufacturing partnerships.
A detailed and integrated segmentation analysis that connects containment choices, vessel classes, liquefaction technology, and application demands to practical deployment decisions and contracting outcomes
Segmentation insights clarify where technical choices and commercial use cases intersect to shape deployment pathways and tender specifications. Based on Containment System, market is studied across Membrane and Moss, and this distinction governs not only initial capex and maintainability but also implications for payload efficiency, inspection regimes, and cold chain interfaces. Based on Vessel Type, market is studied across FLNG, FSRU, and FSU, with each vessel class offering distinct operational profiles: FLNGs integrate upstream processing and liquefaction, FSRUs focus on regasification and shore supply flexibility, and FSUs provide strategic storage and bridging capacity for market imbalances. Based on Technology, market is studied across C3MR, Mixed Refrigerant, and Propane Precooling; the Mixed Refrigerant is further studied across Dual Mixed Refrigerant and Single Mixed Refrigerant, and these selection pathways influence plant footprint, start-up behavior, turndown performance, and refrigerant handling protocols.
Based on Application, market is studied across Industrial Process, Power Generation, Regasification, and Shipping Fuel, which determines duty cycles, contract tenor expectations, and integration with onshore receiving terminals. Based on Storage Capacity, market is studied across 100 To 180 K Cubic Meter, Above 180 K Cubic Meter, and Up To 100 K Cubic Meter, and capacity thresholds affect mooring arrangements, transshipment approaches, and commercial flexibility for spot cargo handling. Based on End User, market is studied across Industrial Manufacturing, Petrochemicals, Transportation, and Utilities, and each end user group has differing risk appetites, payment structures, and technical integration needs. Based on Operational Status, market is studied across Operational, Planned, and Under Construction, which provides a lens on execution performance, asset readiness, and near-term supply availability. Together, these segmentation lenses enable stakeholders to map technology choices to specific business objectives and regulatory contexts.
A regionally focused synthesis that explains how Americas, Europe Middle East & Africa, and Asia-Pacific dynamics shape project design, contracting, and deployment sequencing for floating LNG
Regional dynamics continue to exert outsized influence on where floating liquefied natural gas projects are prioritized and how they are structured commercially. In the Americas, the proximity to large gas basins and established maritime infrastructure supports a mix of export-oriented and domestic use cases; project sponsors often benefit from deep fabrication capacity and a competitive supply base, while regional regulatory frameworks emphasize safety and environmental oversight. In Europe, Middle East & Africa, the landscape is heterogeneous: the Middle East hosts competitive feedstock and capital availability that favors large-scale, longer-duration projects, Europe is focused on energy security and decarbonization which elevates flexibility and emissions credentials, and parts of Africa present high upside for gas monetization using floating solutions where onshore infrastructure is limited.
Asia-Pacific continues to be the primary demand hub, driven by population centers with growing gas consumption and a strong appetite for diverse supply sources. The region’s demand profile has encouraged the adoption of FSRUs to rapidly increase import capacity and FLNG solutions in select offshore fields where onshore development is constrained. Across all regions, policy drivers such as carbon pricing, methane regulation, and local content rules are shaping contracting strategies and investor due diligence. These regional contours determine vessel routing, mooring solutions, and commercial structures, and they should inform where capital is allocated and which technical designs are prioritized for competitive tendering.
An authoritative overview of the competitive ecosystem and service-provider landscape that highlights execution capabilities, partnership models, and aftermarket value propositions essential to floating LNG success
The competitive field for floating liquefied natural gas is characterized by a small number of specialized technology licensors, major shipyards with integrated fabrication capabilities, and a growing set of service providers that focus on digital operations, cryogenic maintenance, and lifecycle support. These players compete on execution track record, technology robustness, vessel reliability, and the ability to provide integrated service packages that span EPC, long-term operations, and spare parts supply. Partnerships and consortiums remain a common strategy to distribute execution risk and to combine upstream expertise with marine engineering and port services.
In addition to pure-play technology suppliers and shipbuilders, increasingly important roles are being played by engineering contractors who can offer modularized delivery models that reduce interface complexity and shorten commissioning windows. The aftermarket and operations segment is also evolving: specialized providers offering remote monitoring, emissions detection, and predictive maintenance services are adding tangible value by lowering operational interruptions and enabling more precise performance guarantees. Finally, financiers and insurers with sector specialization are influencing contractual norms by requiring enhanced due diligence on supply chains, environmental risk, and operational resilience, which in turn shapes how companies position their capabilities to win contracts in a more discerning procurement environment.
Practical and prioritized strategic recommendations for industry leaders to strengthen supply chains, embed emissions controls, and structure flexible commercial contracts to de-risk floating LNG initiatives
Industry leaders should adopt a pragmatic set of actions to capture opportunity while managing execution and policy risks. First, prioritize supply-chain diversification and nearshoring strategies that reduce exposure to tariff shocks and single-source dependencies. This includes qualifying alternate fabricators and negotiating staged delivery terms that align payment milestones with demonstrable progress. Second, integrate emissions management and methane-detection technologies into early design stages to meet tightening regulatory expectations and to preserve offtaker and investor confidence. Embedding leak detection and low-emissions compressors at FEED can materially lower retrofit risk later in an asset’s life.
Third, structure commercial contracts with flexible redeployment clauses and hybrid pricing mechanisms that allow assets to move between export, regasification, and storage duties without onerous penalties. Fourth, invest in digital operations and predictive maintenance capabilities to extend mean time between failures and to reduce planned downtime windows, thus protecting revenue streams. Fifth, pursue strategic alliances with local partners to navigate regulatory landscapes and to access regional incentives. Finally, engage proactively with insurers and lenders early in the design process to align risk transfer mechanisms and to avoid last-minute underwriting constraints that can delay financial close.
A transparent description of the mixed-methods research approach that combines primary interviews, technical literature, and corroborating operational evidence to derive actionable insights for stakeholders
This study draws on a blended research methodology that combines technical literature review, primary stakeholder engagement, and cross-validation with operational data from active floating assets. Primary engagement included structured interviews with project developers, shipbuilders, technology licensors, operators, and financiers to surface execution challenges, procurement adaptations, and evolving contractual norms. Technical literature and industry standards provided the foundation for assessing containment systems, refrigerant cycles, and vessel classes, while regulatory documentation informed the analysis of emissions and compliance trends.
Where possible, findings were corroborated through operator disclosures, public filings, and third-party engineering assessments to ensure alignment between stated practices and observed operational outcomes. Scenario analysis was applied qualitatively to explore how tariff measures, policy changes, and supply-chain shifts might influence procurement and scheduling decisions, and sensitivity considerations were used to surface potential inflection points for strategy. The methodology emphasizes triangulation across sources and disciplines to produce insights that are both actionable for practitioners and robust under a range of commercial and policy conditions.
A concise conclusion that synthesizes the strategic imperatives and execution criteria essential for successful floating LNG project development and long-term operational resilience
In conclusion, floating liquefied natural gas represents a versatile set of technical and commercial solutions that can address specific resource, regulatory, and market constraints when deployed with disciplined procurement, emissions-conscious design, and adaptive commercial structures. The convergence of modular engineering, advanced refrigeration cycles, and digital operations increases the viability of floating solutions across a wider set of geographies and use cases than previously feasible. However, the environment is complex: policy changes such as tariffs and emissions mandates introduce layers of strategic uncertainty that must be managed through diversified sourcing, early stakeholder alignment, and contract structures that permit flexibility.
Looking ahead, the projects that will succeed are those that combine technical robustness with agile commercial design, transparent emissions governance, and proven execution partners. By foregrounding supply-chain resilience, local partnerships, and digital-enabled maintenance, developers and operators can better control schedule risk and sustain operational performance. The concluding message is that thoughtful integration of technical choices with commercial strategy and regulatory foresight will be the differentiator between projects that meet stakeholder expectations and those that face costly delays or reputational risk.
Note: PDF & Excel + Online Access - 1 Year
Table of Contents
187 Pages
- 1. Preface
- 1.1. Objectives of the Study
- 1.2. Market Segmentation & Coverage
- 1.3. Years Considered for the Study
- 1.4. Currency
- 1.5. Language
- 1.6. Stakeholders
- 2. Research Methodology
- 3. Executive Summary
- 4. Market Overview
- 5. Market Insights
- 5.1. Adoption of digital twin technology for real-time monitoring and predictive maintenance on FLNG vessels
- 5.2. Expansion of small-scale modular FLNG units to unlock stranded gas reserves in offshore and onshore fields
- 5.3. Integration of carbon capture utilization and storage solutions into floating LNG facilities for decarbonization
- 5.4. Strategic partnerships between oil majors and EPC contractors to accelerate turnkey FLNG project delivery
- 5.5. Evolution of floating storage regasification units as flexible midstream infrastructure in regional gas markets
- 5.6. Rising investment in ammonia co-production on FLNG platforms to diversify product slate and optimize economics
- 5.7. Emergence of LNG bunkering hubs supported by FLNG supply vessels to meet growing maritime fuel demand
- 5.8. Development of standardized hull and topside designs to drive cost reduction across successive FLNG deployments
- 6. Cumulative Impact of United States Tariffs 2025
- 7. Cumulative Impact of Artificial Intelligence 2025
- 8. Floating Liquefied Natural Gas Market, by Containment System
- 8.1. Membrane
- 8.2. Moss
- 9. Floating Liquefied Natural Gas Market, by Vessel Type
- 9.1. FLNG
- 9.2. FSRU
- 9.3. FSU
- 10. Floating Liquefied Natural Gas Market, by Technology
- 10.1. C3MR
- 10.2. Mixed Refrigerant
- 10.2.1. Dual Mixed Refrigerant
- 10.2.2. Single Mixed Refrigerant
- 10.3. Propane Precooling
- 11. Floating Liquefied Natural Gas Market, by Storage Capacity
- 11.1. 100 To 180 K Cubic Meter
- 11.2. Above 180 K Cubic Meter
- 11.3. Up To 100 K Cubic Meter
- 12. Floating Liquefied Natural Gas Market, by Operational Status
- 12.1. Operational
- 12.2. Planned
- 12.3. Under Construction
- 13. Floating Liquefied Natural Gas Market, by Application
- 13.1. Industrial Process
- 13.2. Power Generation
- 13.3. Regasification
- 13.4. Shipping Fuel
- 14. Floating Liquefied Natural Gas Market, by End User
- 14.1. Industrial Manufacturing
- 14.2. Petrochemicals
- 14.3. Transportation
- 14.4. Utilities
- 15. Floating Liquefied Natural Gas Market, by Region
- 15.1. Americas
- 15.1.1. North America
- 15.1.2. Latin America
- 15.2. Europe, Middle East & Africa
- 15.2.1. Europe
- 15.2.2. Middle East
- 15.2.3. Africa
- 15.3. Asia-Pacific
- 16. Floating Liquefied Natural Gas Market, by Group
- 16.1. ASEAN
- 16.2. GCC
- 16.3. European Union
- 16.4. BRICS
- 16.5. G7
- 16.6. NATO
- 17. Floating Liquefied Natural Gas Market, by Country
- 17.1. United States
- 17.2. Canada
- 17.3. Mexico
- 17.4. Brazil
- 17.5. United Kingdom
- 17.6. Germany
- 17.7. France
- 17.8. Russia
- 17.9. Italy
- 17.10. Spain
- 17.11. China
- 17.12. India
- 17.13. Japan
- 17.14. Australia
- 17.15. South Korea
- 18. Competitive Landscape
- 18.1. Market Share Analysis, 2024
- 18.2. FPNV Positioning Matrix, 2024
- 18.3. Competitive Analysis
- 18.3.1. Bechtel Corporation
- 18.3.2. BW Group
- 18.3.3. Chevron Corporation
- 18.3.4. Chiyoda Corporation
- 18.3.5. CNOOC
- 18.3.6. Eni S.p.A.
- 18.3.7. Excelerate Energy Inc.
- 18.3.8. Exmar NV
- 18.3.9. Exxon Mobil Corporation
- 18.3.10. Golar LNG Limited
- 18.3.11. Höegh LNG
- 18.3.12. Hyundai Heavy Industries Holdings Co. Ltd.
- 18.3.13. KBR Inc.
- 18.3.14. Mitsubishi Heavy Industries Ltd.
- 18.3.15. Mitsui O.S.K. Lines Ltd.
- 18.3.16. MODEC Inc.
- 18.3.17. New Fortress Energy
- 18.3.18. Petronas
- 18.3.19. QatarEnergy LNG
- 18.3.20. Saipem S.p.A.
- 18.3.21. Samsung Heavy Industries Co. Ltd.
- 18.3.22. Shell plc
- 18.3.23. Technip Energies N.V.
- 18.3.24. TotalEnergies SE
- 18.3.25. Woodside Energy Group
Pricing
Currency Rates
Questions or Comments?
Our team has the ability to search within reports to verify it suits your needs. We can also help maximize your budget by finding sections of reports you can purchase.
